Compositions and methods for well completions

ABSTRACT

Expansive cements for use in cementing subterranean wells comprise water, an inorganic cement and one or more particulate materials that swell upon contact with a water-immiscible fluid. The cements may further comprise a water-immiscible fluid. Such cements are designed to seal microannuli arising from the presence of water-immiscible fluids on casing surfaces, borehole wall surfaces or both.

BACKGROUND

The statements in this section merely provide background informationrelated to the present disclosure and may not constitute prior art.

This disclosure relates to compositions and methods for treatingsubterranean formations, in particular, compositions and methods forcementing subterranean wells.

During the construction of subterranean wells, it is common, during andafter drilling, to place a tubular body in the wellbore. The tubularbody may comprise drillpipe, casing, liner, coiled tubing orcombinations thereof. The purpose of the tubular body is to act as aconduit through which desirable fluids from the well may travel and becollected. The tubular body is normally secured in the well by a cementsheath. The cement sheath provides mechanical support and hydraulicisolation between the zones or layers that the well penetrates. Thelatter function is important because it prevents hydraulic communicationbetween zones that may result in contamination. For example, the cementsheath blocks fluids from oil or gas zones from entering the water tableand polluting drinking water. In addition, to optimize a well'sproduction efficiency, it may be desirable to isolate, for example, agas-producing zone from an oil-producing zone. The cement sheathachieves hydraulic isolation because of its low permeability. Inaddition, intimate bonding between the cement sheath and both thetubular body and borehole is necessary to prevent leaks.

Poor cement-sheath bonding may have several negative consequences.Interzonal hydraulic communication may (1) interfere with proper wellproduction, (2) allow formation fluids to corrode the casing, and (3)result in an environmental incident should hydrocarbons or saline fluidscommingle with aquifers. The effectiveness of stimulation treatments mayalso be hampered, further limiting well production. Frequently, poorbonding is manifested by the presence of gaps, or “microannuli,” alongthe cement/casing interface, the cement/formation interface or both.

Cement systems that expand slightly (preferably less than about 1%linear expansion) after setting are a proven means for sealingmicroannuli and improving primary cementing results. The improvedbonding is the result of mechanical resistance or tightening of thecement against the pipe and formation.

Some expansive cement systems rely upon the formation of the mineralettringite to induce expansion. Ettringite is a calcium sulfoaluminatemineral that forms when the aluminate phases in portland cement reactwith various forms of added calcium sulfate (usually calcium sulfatehemihydrate). Ettringite crystals have a larger bulk volume than thereactants from which they form; consequently, expansion occurs becauseof the internal pressure exerted upon crystallization. A limitation ofettringite-based systems is their inability to provide significantexpansion at curing temperatures above about 76° C. (170° F.).Ettringite is not stable at higher temperatures and converts to anothersulfoaluminate mineral that does not impart expansion.

Another type of expanding cements involves cement slurries containinghigh concentrations of NaCl, Na₂SO₄, or both. After the cement sets,cement expansion occurs because of internal pressure exerted by thecrystallization of the salts within pores, and by chlorosilicate andchlorosulfoaluminate reactions. These systems may be effective attemperatures up to 204° C. (400° F.). However, the high cement-slurrysalinity may cause casing corrosion, and may interfere with theperformance of other cement additives—fluid-loss additives inparticular.

Zinc, magnesium, iron and aluminum powders may be used to prepareexpansive cements. When added to the high-pH environment of aportland-cement slurry, the metals react and produce hydrogen-gasbubbles. The resulting pressurization causes the cement to expand aftersetting; however, the effectiveness of these additives may be limited bythe ideal-gas law as well depth increases. In addition, the expansiveeffect may be temporary as the increased pore pressure may dissipatewith time.

Addition of calcined calcium oxide or magnesium oxide also may result incement expansion after setting. The oxide hydration results in theformation of a hydroxide that is less dense than the reactants, therebyproviding an expansive force within the cement matrix. These oxidesystems have been employed at temperatures up to about 260° C. (500°F.); however, the rate at which they react, and hence the expansiongenerated, may be difficult to control. If the additive hydrates tooquickly (e.g., before the cement sets), little or no cement expansionwill occur. If the additives hydrate too slowly, the expansion may occurtoo late and allow interzonal communication.

A more complete discussion of current expansive cement systems may befound in the following publication. Nelson E B, Drochon B, Michaux M andGriffin T J: “Special Cement Systems,” in Nelson E B and Guillot D.(eds.): Well Cementing (2^(nd) Edition), Schlumberger, Houston (2006)233-268.

SUMMARY

This summary is provided to introduce a selection of concepts that arefurther described below in the detailed description. This summary is notintended to identify key or essential features of the claimed subjectmatter, nor is it intended to be used as an aid in limiting the scope ofthe claimed subject matter.

The present application describes a cement system that seals microannuliarising from the presence of water immiscible fluids on the formation,tubular-body surfaces or both.

In an aspect, embodiments relate to methods for cementing a subterraneanwell having a casing and a borehole surface. The borehole surface and anouter surface of the casing are coated with a water immiscible fluid. Acomposition is provided that comprises water, an inorganic cement andone or more particulate materials that swell upon contact with the waterimmiscible fluid, wherein the composition is not an emulsion. Thecomposition is then placed into the well such that the compositioncontacts the water immiscible fluid. The well has been drilled with awater-base drilling fluid.

In a further aspect, embodiments relate to methods for cementing asubterranean well having a casing and a borehole surface. The boreholesurface and an outer surface of the casing are coated with a first waterimmiscible fluid. A composition is provided that comprises water, aninorganic cement, a second water immiscible fluid and one or moreparticulate materials that swell upon contact with a water immisciblefluid, wherein the composition is not an emulsion. The composition isthen placed into the well.

The subterranean well has been drilled by a non-aqueous drilling fluid.

In yet a further aspect, embodiments relate to cementing a subterraneanwell having a casing and a borehole surface. A composition is providedthat comprises water, an inorganic cement, a first water immisciblefluid and one or more particulate materials that swell upon contact witha water immiscible fluid, wherein the composition is not an emulsion.The well has been drilled by water-base drilling fluid.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a graph showing the linear-expansion behavior of cementsystems containing swellable particles and crude oil.

FIG. 2 is a graph showing the linear-expansion behavior of a cementsystem containing swellable particles and immersed in a syntheticoil-base mud.

DETAILED DESCRIPTION

In the following description, numerous details are set forth to providean understanding of the present disclosure. However, it may beunderstood by those skilled in the art that the methods of the presentdisclosure may be practiced without these details and that numerousvariations or modifications from the described embodiments may bepossible.

At the outset, it should be noted that in the development of any suchactual embodiment, numerous implementation—specific decisions are madeto achieve the developer's specific goals, such as compliance withsystem related and business related constraints, which will vary fromone implementation to another. Moreover, it will be appreciated thatsuch a development effort might be complex and time consuming but wouldnevertheless be a routine undertaking for those of ordinary skill in theart having the benefit of this disclosure. In addition, the compositionused/disclosed herein can also comprise some components other than thosecited. In the summary of the disclosure and this detailed description,each numerical value should be read once as modified by the term “about”(unless already expressly so modified), and then read again as not somodified unless otherwise indicated in context. The term about should beunderstood as any amount or range within 10% of the recited amount orrange (for example, a range from about 1 to about 10 encompasses a rangefrom 0.9 to 11). Also, in the summary and this detailed description, itshould be understood that a concentration range listed or described asbeing useful, suitable, or the like, is intended that any concentrationwithin the range, including the end points, is to be considered ashaving been stated. For example, “a range of from 1 to 10” is to be readas indicating each possible number along the continuum between about 1and about 10. Furthermore, one or more of the data points in the presentexamples may be combined together, or may be combined with one of thedata points in the specification to create a range, and thus includeeach possible value or number within this range. Thus, even if specificdata points within the range, or even no data points within the range,are explicitly identified or refer to a few specific, it is to beunderstood that inventors appreciate and understand that any data pointswithin the range are to be considered to have been specified, and thatinventors possessed knowledge of the entire range and the points withinthe range.

As stated earlier, there is a need for cement systems having the abilityto seal microannuli that arise from the presence of water-immisciblefluids or shrinkage of cements along casing or borehole wall surfaces,or both. Applicant has provided such systems by incorporatingparticulate materials that are susceptible to swelling when exposed towater-immiscible fluids.

When a water immiscible fluid is incorporated in the cement slurry, theswellable particles may cause the slurry to expand and fill themicroannuli during the setting process. Alternatively, if a waterimmiscible fluid is applied to an outer casing surface and the formationsurface before the annulus is filled with the disclosed cementcompositions, the swellable particles therein may contact the immisciblefluid coating. The particle swelling may then cause the cement sheath toswell and seal the regions having residual water immiscible fluid. Thecasing and borehole surfaces may be coated by pumping a water immisciblefluid pill into the well.

Therefore, in an aspect, embodiments relate to methods for cementing asubterranean well having a casing and a borehole surface. A drilling rigis brought to the wellsite. A drill string and drill bit create aborehole, or well, that penetrates one or more subterranean formations.A water-base drilling fluid is employed to lubricate the drill bit andtransport drill cuttings to the surface. The drill string is removed anda casing string is inserted into the well. The borehole surface and anouter surface of the casing are then coated with a water immisciblefluid. A composition is provided that comprises water, an inorganiccement and one or more particulate materials that swell upon contactwith the water immiscible fluid, wherein the composition is not anemulsion. In other words, the water immiscible fluid is not encapsulatedby the water, nor is the water encapsulated by the water immisciblefluid. As a result, the swellable particles have direct access to thewater immiscible fluid substantially immediately upon mixing of thecomposition. The composition is then placed into the well such that thecomposition contacts the water immiscible fluid.

In a further aspect, embodiments relate to cementing a subterranean wellhaving a casing and a borehole surface. A drilling rig is brought to thewellsite. A drill string and drill bit create a borehole, or well, thatpenetrates one or more subterranean formations. A water-base drillingfluid is employed to lubricate the drill bit and transport drillcuttings to the surface. The drill string is removed and a casing stringis inserted into the well. The borehole surface and an outer casingsurface are then coated with a first water-immiscible fluid. Acomposition is provided that comprises water, an inorganic cement, asecond water immiscible fluid and one or more particulate materials thatswell upon contact with the first and second water immiscible fluids,wherein the composition is not an emulsion. The composition is thenplaced into the well such that the composition contacts the first waterimmiscible fluid. The first and second water immiscible fluids may bethe same.

In yet a further aspect, embodiments relate to cementing a subterraneanwell having a casing and a borehole surface. A drilling rig is broughtto the wellsite. A drill string and drill bit create a borehole, orwell, that penetrates one or more subterranean formations. A water-basedrilling fluid is employed to lubricate the drill bit and transportdrill cuttings to the surface. The drill string is removed and a casingstring is inserted into the well. A composition is provided thatcomprises water, an inorganic cement, a first water-immiscible fluid andone or more particulate materials that swell upon contact with thewater-immiscible fluid, wherein the composition is not an emulsion. Thecomposition is placed into the well. Optionally, an outer casing surfaceand the borehole surface may be coated by a second water-immisciblefluid.

The preparation of the composition or slurry may occur at the surfacewith either batch mixing or continuous mixing equipment as is known inthe art. A complete description of the design and operation of cementmixing equipment may be found in the following publication: Leugemors E,Metson J, Pessin, J-L, Colvard R L, Krauss C D and Plante M: “CementingEquipment and Casing Hardware,” in Nelson E B and Guillot D: WellCementing—Second Edition, Houston, Schlumberger (2006): 343-434.

For all aspects, the casing surface may be composed of carbon steel,stainless steel, alloys such as INCONEL and MONEL, or a compositematerial containing a high temperature resin. The borehole surface maybe a rock surface such as (but not limited to) a sandstone, a limestone,an evaporite or a shale.

For all aspects, the inorganic cement may be chosen from one or moremembers of the following list: portland cement, calcium aluminatecement, lime-silica blends, geopolymers, Sorel cements, chemicallybonded phosphate ceramics, zeolites and cement-kiln dust. The cementsmay further comprise extenders such as fly ash, blast-furnace slag,silica, silica fume, nanosilica and nanoalumina.

For all aspects, the swellable particulate material may comprise groundrubber, polypropylene, uintaite, poly-2, 2, 1-bicyclo heptene(polynorbornene), alkylstyrene, crosslinked substituted vinyl acrylatecopolymers, polyisoprene, polyvinyl acetate, polychloroprene,acrylonitrile butadiene, hydrogenated acrylonitrile butadiene, ethylenepropylene diene monomer, ethylene propylene monomer, styrene-butadiene,styrene/propylene/diene monomer, brominatedpoly(isobutylene-co-4-methylstyrene), chlorosulphonated polyethylenes,polyacrylates, polyurethanes, silicones, chlorinated polyethylene,epichlorohydrin ethylene oxide copolymer, ethylene acrylate rubber,ethylene propylene diene terpolymers, sulphonated polyethylene,fluorosilicones, fluoroelastomer, substituted styrene acrylatecopolymers and mixtures thereof. The swellable particulate material mayalso comprise ground rubber, polypropylene or unitaite or combinationsthereof. Uintaite is a generic name for Gilsonite™—produced by theAmerican Gilsonite Company.

The particle size of the swellable material may be between about 1micrometer and 1 millimeter, or between about 10 micrometer and 1millimeter or between about 100 micrometer and 1 millimeter. Theconcentration of the swellable material may be between about 1% and 50%by volume of the composition, or between about 1% and 35% by volume ofthe composition or between about 1% and 25% by volume of thecomposition.

For all aspects, the water-immiscible fluid may comprise crude oil,mineral oil, diesel oil, vegetable oil, linear alpha-olefins, xylene ortoluene or combinations thereof. The volumetric concentration of thewater-immiscible fluid in the composition may be between about 0.5% and50%, or between 0.5% and 25% or between 0.5% and 10%.

For all aspects, the composition may further comprise expanding agentsthat include calcium sulfate hemihydrate, sodium chloride, sodiumsulfate, aluminum powder, zinc powder, iron powder, magnesium powder,calcium oxide or magnesium oxide or combinations thereof. Theconcentration of the expanding agents may be between 0.5% and 15.0% byweight of cement (BWOC), or between 1.0% and 10.0% BWOC or between 1.0%and 5.0% BWOC.

For all aspects, the composition may also comprise customary additivessuch as retarders, accelerators, extenders, fluid-loss-controladditives, lost-circulation additives, gas-migration additives, gasgenerating additives and antifoam agents. Further information concerningthese materials may be found in the following publication: Nelson E B,Michaux M and Drochon B: “Cement Additives and Mechanisms of Action,” inNelson E B and Guillot D (eds): Well Cementing—Second Edition, Houston,Schlumberger (2006): 49-91.

Furthermore, the compositions may contain additives that enhance theflexibility and/or toughness of the set cement. Such additives includeflexible particles having a Young's modulus below about 5,000 MPa and aPoisson's ratio above about 0.3. The particles may have a Young'smodulus below about 2,000 MPa. Examples include polyethylene,acrylonitrile butadiene, styrene butadiene, polyamide,polytetrafluoroethylene, polyether ether ketone, perfluoroalkoxy polymerresin, fluorinated ethylenepropylene, polyethylenetetrafluoroethylene,polyvinylfluoride, polychlorotrifluororethylene, perfluoroelastomers,fluorocarbon elastomers and combinations thereof. Such additives mayalso include fibers selected from the list comprising polyamide,polyethylene and polyvinyl alcohol. Metallic microribbons may also beincluded. These materials may be present in the composition atconcentrations between 1% and 50% by volume, or between 2% and 25% byvolume or between 5% and 10% by volume.

The swellable particles may also be used in engineered-particle-sizecement formulations involving multimodal blends of small, medium andcoarse particles.

The water-immiscible fluid may comprise (but would not be limited to)mineral oil, diesel oil, vegetable oil, linear alpha-olefins, xylene,toluene and combinations thereof. The water-immiscible fluid may notirremediably affect the performance of cement additives present in theexternal phase. The volumetric concentration of the water-immisciblefluid may be between about 1% and about 50% of the total fluid volume,more preferably between about 5% and about 25% of the total fluidvolume, and most preferably between about 10% and about 20% of the totalfluid volume.

The level of expansion may be controlled by the type of swellableparticles, the swellable-particle concentration and/or the volumetricratio between the swellable particles and the water-immiscible fluid.Furthermore, the swellable particles may also impart cement-sheathflexibility by reducing the Young's modulus of the set cement. The levelof linear expansion may be as high as 5%, as high as 3% or as high as1%.

Those skilled in the art will appreciate that the disclosed method anduse may not necessarily be applied throughout the entire length of thesubterranean interval being cemented. In such cases, more than onecement-slurry composition is placed sequentially. The first slurry iscalled the “lead,” and the last slurry is called the “tail.” Under thesecircumstances, the expanding cement composition may be placed such thatit resides in regions where hydrocarbons exist. In most cases, this willbe at or near the bottom of the well; therefore, expanding cementcomposition may be the tail. Those skilled in the art will alsoappreciate that the disclosed method and use would not only be usefulfor primary cementing, but also for remedial cementing operations suchas squeeze cementing and plug cementing.

Other and further objects, features and advantages of the presentdisclosure will be readily apparent to those skilled in the art upon areading of the description of the examples which follows, taken inconjunction with the accompanying drawings.

EXAMPLES

The following examples serve to further illustrate the disclosure.

The following base cement slurry was employed for Examples 1 and 2(Table 1). The slurry density was 1,400 kg/m³ (11.65 lbm/gal). The solidvolume fraction (SVF) was 50.5%.

TABLE 1 Base slurry composition Material Function Concentration Class Gcement binder 50.2% BWOB* ceramic microspheres extender 18.2% BWOBground rubber swellable particle 16.0% BWOB microfine cement binder16.0% BWOB fresh water — 460 L/tonne** polypropylene glycol antifoamagent 4.2 L/tonne AMPS/acrylate fluid-loss additive 8.4 L/tonne polymersolution polymelamine dispersant 1.7 L/tonne sulfonate calcium retarder0.22% BWOB lignosulfonate *by weight of solid blend; **tonne of solidblend

Three base cement slurries were prepared according to the compositionpresented in Table 1. The slurry preparation was performed according tothe recommended procedures published by the American Petroleum Institute(RP 10B). Tests were performed to measure the linear expansion of cementsystems containing various amounts of oil. In these experiments, crudeoil was added to the base slurry at 0%, 2% and 4% by volume of cementslurry.

Linear expansion tests were conducted according to the recommended APIprocedure described in API Publication RP 10B. An annular ring apparatussimulated the annulus of a well. The cement slurry was poured into theannular portion of the mold, the mold was lowered into a water bath andthe slurry was allowed to cure submerged in water. The test period was30 days and the curing temperature was 75° C. No expansion was observedwith the control slurry containing 0% oil. The 30-day linear expansionsof the 2% and 4% oil systems were 0.295% and 0.465%, respectively (FIG.1).

Example 2

One base slurry was prepared according to the composition presented inTable 1. The slurry preparation was performed according to therecommended procedures published by the American Petroleum Institute(Publication RP 10B). No oil was added to the base slurry. The slurrywas allowed to set and harden.

A 7-day linear expansion test was conducted at 75° C. according to therecommended API procedure described in Publication RP 10B. An annularring apparatus simulated the annulus of a well. The cement slurry waspoured into the annular portion of the mold and allowed to set. Then themold was lowered into a bath filled with a synthetic oil-base mud tosimulate contact with a water immiscible fluid. The linear expansionresult was 2.02% (FIG. 2).

Example 3

A cement slurry was prepared with the following composition (Table 2).The slurry density was 1,900 kg/m³. The SVF was 52.0%.

TABLE 2 Slurry Composition Material Function Concentration Class Gcement binder 36.0% BWOB hematite weighting agent 35.0% BWOB groundrubber swellable particle 16.0% BWOB microfine silica extender 13.0%BWOB fresh water — 407 L/tonne polypropylene glycol antifoam agent 4.2L/tonne polyvinylpyrrolidone fluid-loss additive 54.3 L/tonnepolymelamine dispersant 2.5 L/tonne sulfonate

A shear bond test was conducted according to the API recommendedprocedure (Publication RP 10B). Two steel test molds were cleaned suchthat their surfaces were free of rust or damage. The internal surfacesof the molds were then coated with a crude oil. Then, the molds werefilled to the brim with the cement slurry, and the cement slurry wasallowed to cure at atmospheric pressure and temperature for 72 hours.After curing, the molds were placed in a hydraulic press, and the forcerequired to release the cured cement from each mold was measured. Theforce was then divided by the internal surface area of the mold tocalculate the shear bond strength. The average shear-bond strength was82.7 kPa.

Example 4

The cement slurry of Table 2 was prepared. 3 vol % crude oil was thenmixed into the slurry. The shear bond test described in Example 3 wasthen performed. The average shear-bond strength was 138 kPa.

Comparative Example 1

A neat Class G cement slurry was prepared at a density of 1,900 kg/m³.The slurry did not contain a swellable particulate material. Fresh waterwas the mixing fluid.

The shear bond test described in Example 3 was then performed.

During the shear-bond test, essentially zero force was required todislodge the cement sample and push it out of the mold. No bonding haddeveloped between the cement and the inner mold surface.

Although various embodiments have been described with respect toenabling disclosures, it is to be understood that this document is notlimited to the disclosed embodiments. Variations and modifications thatwould occur to one of skill in the art upon reading the specificationare also within the scope of the disclosure, which is defined in theappended claims.

1. A method for cementing a subterranean well having a casing and aborehole surface, comprising: (i) coating the borehole surface and anouter casing surface with a water-immiscible fluid; (ii) providing acomposition comprising water, an inorganic cement and one or moreparticulate materials that swell upon contact with the water-immisciblefluid, wherein the composition is not an emulsion; and (iii) placing thecomposition into the well such that the composition contacts thewater-immiscible fluid; wherein the subterranean well has been drilledwith a water-base drilling fluid.
 2. The method of claim 1, wherein theinorganic cement comprises one or more members selected from the groupconsisting of portland cement, calcium aluminate cement, lime-silicablends, geopolymers, Sorel cements, chemically bonded phosphateceramics, zeolites and cement-kiln dust.
 3. The method of claim 1,wherein the particulate material comprises one or more members selectedfrom the group consisting of ground rubber, polypropylene, uintaite,poly-2, 2, 1-bicyclo heptene (polynorbornene), alkylstyrene, crosslinkedsubstituted vinyl acrylate copolymers, polyisoprene, polyvinyl acetate,polychloroprene, acrylonitrile butadiene, hydrogenated acrylonitrilebutadiene, ethylene propylene diene monomer, ethylene propylene monomer,styrene-butadiene, styrene/propylene/diene monomer, brominatedpoly(isobutylene-co-4-methylstyrene), chlorosulphonated polyethylenes,polyacrylates, polyurethanes, silicones, chlorinated polyethylene,epichlorohydrin ethylene oxide copolymer, ethylene acrylate rubber,ethylene propylene diene terpolymers, sulphonated polyethylene,fluorosilicones, fluoroelastomer and substituted styrene acrylatecopolymers.
 4. The method of claim 1, wherein the particulate materialhas a particle size between 1 micrometer and 1 millimeter, and theparticulate material is present at a concentration between 1% and 50% byvolume of the composition.
 5. The method of claim 1, wherein thecomposition further comprises calcium sulfate hemihydrate, sodiumchloride, sodium sulfate, aluminum powder, zinc powder, iron powder,magnesium powder, calcium oxide or magnesium oxide or combinationsthereof.
 6. The method of claim 1, wherein the water immiscible fluidcomprises one or more members selected from the group consisting ofcrude oil, mineral oil, diesel oil, vegetable oil, linear alpha-olefins,xylene and toluene.
 7. A method for cementing a subterranean well havinga casing and a borehole surface, comprising: (i) coating an outersurface of the casing and the borehole surface with a firstwater-immiscible fluid; (ii) providing a composition comprising water,an inorganic cement, a second water-immiscible fluid and one or moreparticulate materials that swell upon contact with the first and secondwater-immiscible fluids, wherein the composition is not an emulsion; and(iii) placing the composition into the well such that the compositioncontacts the first water-immiscible fluid; wherein the well has beendrilled with a water-base drilling fluid.
 8. The method of claim 7,wherein the inorganic cement comprises one or more members selected fromthe group consisting of portland cement, calcium aluminate cement,lime-silica blends, geopolymers, Sorel cements, chemically bondedphosphate ceramics, zeolites and cement-kiln dust.
 9. The method ofclaim 7, wherein the particulate material comprises one or more membersselected from the group consisting of ground rubber, polypropylene,uintaite, poly-2, 2, 1-bicyclo heptene (polynorbornene), alkylstyrene,crosslinked substituted vinyl acrylate copolymers, polyisoprene,polyvinyl acetate, polychloroprene, acrylonitrile butadiene,hydrogenated acrylonitrile butadiene, ethylene propylene diene monomer,ethylene propylene monomer, styrene-butadiene, styrene/propylene/dienemonomer, brominated poly(isobutylene-co-4-methylstyrene),chlorosulphonated polyethylenes, polyacrylates, polyurethanes,silicones, chlorinated polyethylene, epichlorohydrin ethylene oxidecopolymer, ethylene acrylate rubber, ethylene propylene dieneterpolymers, sulphonated polyethylene, fluorosilicones, fluoroelastomerand substituted styrene acrylate copolymers.
 10. The method of claim 7,wherein the particulate material has a particle size between 1micrometer and 1 millimeter, and the particulate material is present ata concentration between 1% and 50% by volume of the composition.
 11. Themethod of claim 7, wherein the water immiscible fluid comprises one ormore members selected from the group consisting of crude oil, mineraloil, diesel oil, vegetable oil, linear alpha-olefins, xylene andtoluene, and the second water immiscible fluid is present in thecomposition at a volumetric concentration between 0.5% and 50%.
 12. Themethod of claim 7, wherein the composition further comprises calciumsulfate hemihydrate, sodium chloride, sodium sulfate, aluminum powder,zinc powder, iron powder, magnesium powder, calcium oxide or magnesiumoxide or combinations thereof.
 13. The method of claim 7, wherein thecoating with the first water immiscible fluid comprises pumping a pillpast the casing and borehole surface.
 14. A method for cementing asubterranean well having a casing and a borehole surface, comprising:(i) providing a composition comprising water, an inorganic cement, afirst water-immiscible fluid and one or more particulate materials thatswell upon contact with the water immiscible fluid, wherein thecomposition is not an emulsion; and (iii) placing the composition intothe well; wherein the subterranean well has been drilled with awater-base drilling fluid.
 15. The method of claim 14, wherein theinorganic cement comprises one or more members selected from the groupconsisting of portland cement, calcium aluminate cement, lime-silicablends, geopolymers, Sorel cements, chemically bonded phosphateceramics, zeolites and cement-kiln dust.
 16. The method of claim 14,wherein the particulate material comprises one or more members selectedfrom the group consisting of ground rubber, polypropylene, uintaite,poly-2, 2, 1-bicyclo heptene (polynorbornene), alkylstyrene, crosslinkedsubstituted vinyl acrylate copolymers, polyisoprene, polyvinyl acetate,polychloroprene, acrylonitrile butadiene, hydrogenated acrylonitrilebutadiene, ethylene propylene diene monomer, ethylene propylene monomer,styrene-butadiene, styrene/propylene/diene monomer, brominatedpoly(isobutylene-co-4-methylstyrene), chlorosulphonated polyethylenes,polyacrylates, polyurethanes, silicones, chlorinated polyethylene,epichlorohydrin ethylene oxide copolymer, ethylene acrylate rubber,ethylene propylene diene terpolymers, sulphonated polyethylene,fluorosilicones, fluoroelastomer and substituted styrene acrylatecopolymers.
 17. The method of claim 14, wherein the particulate materialhas a particle size between 1 micrometer and 1 millimeter, and theparticulate material is present at a concentration between 1% and 50% byvolume of the composition.
 18. The method of claim 14, wherein the firstwater immiscible fluid comprises one or more members selected from thegroup consisting of crude oil, mineral oil, diesel oil, vegetable oil,linear alpha-olefins, xylene and toluene, and the water immiscible fluidis present in the composition at a volumetric concentration between 0.5%and 50%.
 19. The method of claim 14, wherein the composition furthercomprises calcium sulfate hemihydrate, sodium chloride, sodium sulfate,aluminum powder, zinc powder, iron powder, magnesium powder, calciumoxide or magnesium oxide or combinations thereof.
 20. The method ofclaim 14, further comprising coating an outer casing surface and theborehole surface with a second water-immiscible fluid.